Field Development & Production Operations
Biography: Jagar Ali was born in March 11th, 1990 in Akre, Kurdistan Region of Iraq. He received a bachelor’s degree with honours in petroleum engineering from Koya University in July, 2011 and a master’s degree in the same major from Heriot-Watt University in September, 2014. His current placement is with Soran University as a head of petroleum engineering department. And in the professional way he is a part-time employee as a cementing field engineer in NPS well services company. He is interested in waterflooding, enhanced oil recovery, reservoir characterization and history matching.
Abstract: The detailed reservoir characterization and modeling is an active part of the technology of the petroleum industry. However, integrating and improving the geological models of the layered system into fluid flow and production simulations is a significant challenge. This could be achieved by using the history match technique, which is very useful for forecasting the production profile and reducing uncertainties in the future. History match is carried out by using the numerical approach and software. This could also be done manually. This methodology could be more time efficient and less expensive than using the specific software technique. In this way, the history match was performed by applying the semi-analytical method. For this purpose a spreadsheet of the Craig-Geffen-Morse (CGM) procedure was prepared to predict the waterflood performance in a layered reservoir i.e. shoreface deposit (upper shorface facies, middle shoreface facies and lower shoreface facies). From the spreadsheet, thicknesses of the layers around each single production well were changed until a good match with the production data was achieved. Then, the history matching between the semi-analytical and eclipse results was applied to the different synthetic sets of data as real historical production information. Consequently, a good match was achieved with one set of the historical data. Therefore, it was then practicable to update the geological model based on the results of the history matching from the semi-analytical method. The field production data of the final semi-analytical model, with the best match, was then compared with 100 stochastic realization models (geological models), models created by the Petrel software. The realization model with the best match was then updated by changing the local facies distributions around all production wells separately to those values gained from the final semi-analytical model. From updating the geological model (best realization model), the height of layers were being more close to the real system and uncertainties of the production data were reduced by about 19.8% (from 21.52% to 1.73%). In conclusion, it is applicable to use the analytical and/or semi-analytical methods for history matching and updating geological models.
Biography: Ing. Pedro Javier Rojas, Petroleum Engineer, with specializations in Senior Management, Project Management, Organizational Management, and Asset Management. He worked at Petrobras, Graña y Montero and Duke Energy Corporation; Developing improvements in Optimization and control of organizational climate. It has a high degree of awareness and internalisation of the sense of ownership, with CSMS knowledge and management (Quality, Safety, Health and Environment). Management Capacity, in ISO 14001, ISO 9001 and OSHAS 18001, and implementation of SGI in Peru. Participant in International Coaching Congresses, Training in Management Management. +17 years of experience, in Operations Management, Contract Management, Head of Plants of Treatment of Crude - Water, Gas Compression, Gas Plant Manager; Extraction Engineer, Production Manager, Operations Manager, in Costa Norte and Selva Central assets in Peru, having developed other studies in Argentina, Venezuela, Brazil, Panama and Colombia.
Abstract: Nowadays, it is increasingly necessary to apply Asset Management, in the Processes of any industry, especially in the nuetra. Given this, there is the best Asset Management strategy applied to any process, provided that an excellent Strategy at the organizational level is defined.
This shows a series of control and monitoring tools, which allows, among other things, to ensure a good way to Operational Excellence, getting rid of problems technically and other things that reduce the day to day management. It presents an Asset Management Strategy applied fundamentally to the Strategy of any organization, being led by the highest levels, with joint participation of all the Staff.
Based on the Continuous Improvement Cycle, any subsequent implementation will have a solid base in order to obtain the clearly defined achievements in the objectives of the Strategic Plan of the company, afterwards it will seek to identify, dimension and control the operational risks that Exist or accompany the operation, allowing this management to continue directly to the Operational Excellence. We will present real measurements of companies where we started this management and the results of this enterprise.
The mechanics of this development brings with it the permanent use of World Class tools, ensuring that in this way we adopt them, allowing professional, technical, human and above all business growth for the welfare of all.
Biography: Cai bo，Born in 1979，Doctor degree, major in Petroleum Engineering，China University of Geosciences(Beijing).Work at Research Institute of Petroleum Exp. and Dev. Langfang (RIPED-Langfang) in July 2005. Mainly engaged in design and field service of hydraulic fracturing treatment, particularly in tight oil and gas and other unconventional reservoir, published 43 technical papers, 11 papers were indexed by EI/SCI
Abstract: ShuLu muddy-limestone tight oil reservoirs is characterized by high buried depth, complex lithology and high breakdown and treatment pressure in comparison with other tight oil reservoirs in our country and abroad. Over the past years many stimulation technologies have been tried such as matrix acidizing, emulsified acid, gelled acid fracturing and hydraulic fracturing, but none can make a breakthrough. In this paper, we based on the successful experiences and models for unconventional formation stimulation, and focused our attention on the bottlenecks problem for ShuLu muddy-limestone tight oil volume stimulation. The core technical idea is to pursue the compatibility of reservoirs and fractures.
Firstly, we made a fundamental change in completion design that different from existing three completion methods and five stimulation tools. This completion method incorporated the screen pipe and casing perforated completion to realize high pumping rate which was benefit for the creation of complex fractures network. Secondly, we conducted a serious of experiments to optimize and evaluate low damage acid and new type fracturing fluids. The new fracturing fluid can sustain high viscosity (100 Pa•s）after 90min test at the condition of 120 ℃、170 s-1. In the meanwhile we conducted acid etched experiments for Muddy Limestone and Breccias with VES acid, and optimized the fracture conductivity of acid etched and propped fracture. Based on the test results we proposed a new hybrid stimulation technology that combined acid fracturing and hydraulic fracturing, and put forward some new methods such as: slug (or alternating) injection, solid-fluid diversion fracturing and channel fracturing. Finally, we formed the high efficient treatment and evaluation techniques after fracturing.
These research results have been applied in ShuTan 1H, ShuTan 1X and ShuTan 3, among them ShuTan 1H was the first time to realize 12.7 m3/min pumping rate at 5000 m well depth, which lay a foundation for high production of 243 t/d, meanwhile ShuTan 3's steady production reached 11 t/d after 3 months through vertical well multi-layer fracturing. The success of these wells can provide new technical guidance for ShuLu and other tight oil formation stimulation.
Biography: Luis Blanc is originally from Barcelona, Spain. He is currently working as an independent Reservoir Engineering Consultant providing project consultancy.
Luis Blanc received a Master degree in Petroleum Engineering from the University of Texas at Austin in 1989. He has over 27 years experience in Reservoir Engineering working for several companies (Exxon USA, Repsol, Shell International, Addax) focusing on asset management and field development planning. He has held technical as well as management positions in a number of locations such as USA, South America (Argentina and Venezuela), Syria, Nigeria, and The Netherlands. His technical expertise is in data integration and validation, reservoir surveillance, reservoir simulation and field development planning.
Abstract: The main theme of this talk is to highlight the importance of establishing a proper and well thought asset depletion plan through a focused well and reservoir management. The main objective of such depletion plan is to maximize asset value. This is extremely important in a low oil price environment such as the one we are currently facing.
It is not uncommon in many asset teams to have an unclear picture of what future actions will be taken to the different wells and reservoirs as they deplete. In many cases, these actions become reactive rather than proactive. This is mainly due to a lack of a well defined reservoir management and depletion plan.
This talk presents practical examples on how to properly design a depletion plan. Such plan would be consistent with the increased understanding of the reservoir behavior obtained from a focused reservoir management. The depletion plan is a comprehensive set of actions that the asset team designs to identify a way forward for every well (identify future workovers, remedial work, gas lift method, all the way to well abandonment) and for every reservoir (identify underdeveloped areas, infill drilling targets, secondary recovery or EOR application, etc
Biography: Mhamed is a supervisor of mineral scale lab with Libyan Petroleum Institute (LPI). He holds BSc. in chemical engineering from AL-Mergab University, Al-Khoms, Libya (2002), and an MPhil degree in petroleum engineering from Herriot-Watt University, Edinburgh, UK, in 2008. Kahrwad has experience in mitigation of scale problems in surface oil facilities, reservoir and well tubular. Kahrwad has published one SPE paper and several technical papers in local conferences.
Abstract: Scale deposition is one of the most serious problems associated with oil production. Scale can occur at dawn-stream of any point in the production system, at which super-saturation is generated due to changes of pressure and temperature conditions. The Libyan oil industry has left a significant legacy of scale formation and methods are required to assess the effectiveness of scale inhibitors.
A laboratory study was conducted to investigate the efficiency of two calcium carbonates (CaCO3) scale inhibitors (7262A &7262B). Four produced water samples were collected from DP3 production wells, DP4 high pressure wells, DP4 low pressure well B4/28, subsea wells B46 & B47. Static efficiency test was used to assess the effectiveness of calcium carbonate crystal growth inhibition in oversaturated solutions containing CaCl2 and NaHCO3 in the absence and presence of various concentrations of selected inhibitors and a sufficient inhibition was recorded. Both scale inhibitors (7262A& 7262B) are effective at high concentrations above 15ppm to inhibit the formation of calcium carbonate based on static evaluation test results. At high level of calcium ion (Ca2+), the efficiency of scale inhibitors is reduced in DP3 produced water. Scanning electron microscope (SEM) and XRD techniques gave two phases of calcium carbonate (Aragonite & Calcite).
Tube blocking tests (TBT) was also performed to determine the inhibitor concentration required to prevent the deposition of scale at operational conditions of temperature and pressure. In this test, pressure and time are the key parameters of carbonate formation. In blank test (without scale inhibitor) formed scale was measured in less than 40 minutes. The optimum concentration of scale inhibitor can be considered at 20ppm as no signal of scale formation was detected.
Drilling & Well operations
Biography: Mr. Abdelaziz Gabr had been graduated from Suez University in Egypt in July 2010.. Then I become a drilling fluids engineer in EMEC company since December 2013 to May 2015. During this time , I worked with giant client Saudi- Aramco in offshore rigs Finally, I am now working as drilling engineer in the biggest oil production company in Egypt called ( Khalda Petroleum Company) which is joint venture to multi-national company ( Apachi ). I am now responsible for development of drilling branch in Petroleum Development Program (PDP) undersupervision of Egyptian Engineering Syndicate.
Abstract: As fields mature and well complexity increases, there is often a dilemma over how to address borehole stability requirements while mitigating the risks of differential sticking and mud losses due to high differential pressures. In these wells where there is little or no operating margin between pore pressure and formation breakdown, options tend to be limited to either running the drilling risks or setting a casing string. Both of these options can be very expensive in terms of equipment and lost rig time.
Stress caging technique is a customized bridging package designed to meet multiple challenges posed in wells where this fine line between wellbore stability, differential sticking, and mud losses exist. It is a combination of state-of-the-art bridging technologies used to provide a multi-pronged system approach to address these issues. It consists of a patented deformable sealing polymer in conjunction with highly resilient graphite additives to reduce pore pressure transmission and seal and plug micro-fractures in shale and low porosity sands. It is mainly used in Saudi- Aramco due to its complicated formations.
These systems utilize mud pressure isolation techniques by creating an Ultra-low permeable, finely packed and slick filter cake across zones of different pressure regimes. These systems is used in drilling wells with overbalance up to 3000 PSI in a safer and more cost effective manner while mitigating drilling hazards and thereby reducing Non- Productive Time (NPT). MAX-BRIDGE for Baker Hughes and HYDRO-GUARD for Baroid are the most common stress caging techniques in oil field nowadays.
Biography: MY NAME IS ANDRES BOADA, I’M 29 YEARS OLD AND I’M PETROLEUM ENGINEER. I’M FROM VENEZUELA.
I STUDIED AT UNIVERSIDAD DE ORIENTE IN VENEZUELA AND NOW I’M WORKING AT BOHAI DRILLING COMPANY AS MWD/LWD ENGINEER
DIRECTIONAL DRILLING IS DEFINED AS THE INTENTIONAL DEVIATION OF A WELL FROM THE PATH IT WOULD NATURALLY TAKE. THIS DEVIATION IS ACHIEVED THROUGH THE USE OF WEDGES, WELL BOTTOM ARRANGEMENTS (BHA), INSTRUMENTS TO MEASURETHE PATH OF THE WELL TO SURFACE, BOTTOM ENGINES, AND BHA COMPONENTS AND SPECIAL DRILL BITS, INCLUDING ROTARY SYSTEMS DIRECTIONAL AND DRILL BITS.
TYPES OF DIRECTIONAL DRILLING
THE WELL IS PLANNED SO THAT THE INITIAL DEVIATION IS OBTAINED AT SHALLOW DEPTH. THE ANGLE OF INCLINATION REMAINS CONSTANT UNTIL REACHING THE TARGET, THIS CONFIGURATION IS MAINLY USED DOR MODERATELY DEEP WELLS.
IT IS THE CONFIGURATION WELL IN “S”. THE DEFLECTION ALSO STARTS NEAR THE SURFACE, THE INCLINATION IS MAINTAINED THE SAME AS IN TYPE 1 UNTIL ALMOST ALL LATERAL DISPLACEMENT IS ACHIEVED. THE ANGLE OF DEVIATION IS THEN REDUCED TO THE VERTICAL TO CARRY THE TARGET. THIS CONFIGURATION IS MAINLY USED TO DRILL WELLS WITH MULTIPLE PRODUCER INTERVALS.
THE DEVIATION BEGINS WELL BELOW THE SURFACE AND THE AVERAGE INCLINE ANGLE IS MAINTAINED UNTIL REACHING THE TARGET. THIS CONFIGURATION IS USED.
HORIZONTAL, MULTILATERAL AND EXTENDED RANGE.
THE PRODUCTIVITY OF THE HORIZONTAL WELLS BECOMES GREATER THAN THAT OF A VERTICL WELL. THEY COMMUNICATE A LARGER AREA OF PRODUCTION FORMATION, TRAVERSE NATURAL FRACTURES, REDUCE PRESSURE DROPS AND DELAY THE ADVANCES OF WATER-OIL OR GAS-OIL CONTACTS.
DIRECTIONAL WELL APPLICATION
- SEVERAL WELLS FROM ARTIFICIAL STRUCTURES
- PERFORATION IN GEOLOGICAL FAULTS
- INACCESSIBLE LOCATIONS
- LATERAL DEVIATION AND STRAIGHTENING
- PERFORATION OF SALINE DOMES
- RELIEF WELLS
TAKING INTO ACCOUNT THAT THE TECNOLOGY IN EXPLORATORY WELL DRILLING OPERATIONS IS MORE ADVANCED, IT IS NECESSARY TO BE AWARE OF THESE ADVANCES.
SINCE THE BEGINNING OF THE HISTORY OD DRILLING THE DRILLING HAS BEEN VERY IMPORTANT AND ITS ADVANCES IN TERMS OF DESIGN AND CNSTRUCTION SHOULD NO DISTURB, THEREFORE WE MUST BE AWARE OF THIS.
IT IS IMPORTANT TO KEEP IN MIND THAT EVERY COMPANY HAS ITS OWN SPECIFICATIONS AT THE TIME TO DRILL, BUT THEY HAVE A COMMON GOAL TO DEVELOP A TECHNOLOGY THAT ALLOWS US TO ADVANCE DRILLING AT THE LOWEST POSSIBLE COST AND WITH THE BEST SAFETY CONDITIONS.
Biography: Mr. Mohammad Ali Ekhtiari,Is the PhD student of University College Dublin, Ireland. He is doing his research on “Modelling of Gas Networks in an Interconnected Energy System” under supervision of Dr. Syron as the principle supervisor.
Abstract: With an increase in discontinious and sometimes unpredictable renewable electricity coming on-line there is an associated increase in the importance of energy storage to balance supply and demand. This is especially true in remote or segmented regions with limited or no Natural Energy Resources.As an example, in Ireland, up to 40% of the peak daily electricity demand can be supplied through wind power. In many instances through network limitations it is not possible to accept all available wind power on to the elcetricy network and concequently this leads to wind-energy dispatch-down.The gas Network can provide the facility to store and transport this energy through the use of technoilogies such as Power to Gas (P2G).
In this study using the island of Ireland as an example several scenarios were examined using P2G to store excess wind power. These scenatios looked at both electrical and gas network constraints as well as various end uses for the syntetic natural gas. It was found that the location of the P2G installation, and its connection to both the electrical and gas network are crucial factors when a balance must be found between maximizing the efficiency of the energy storage system and the economic feasibility of using a P2G for energy storage.
Biography: Syamalendu Sekhar Bandyopadhyay received his Ph.D in chemical engineering from Indian Institute of Technology Kharagpur , India. During his 32 years of academic experience, he served as the chairman of Cryogenic Engineering Centre at IIT and member of advisory committee of carbon dioxide sequestration research of DST, editor of Indian Chemical Engineer , visiting professor at UCDAVIS and university of Waterloo. He is the lead editor of the book Advances in Separation Processes, delivered several invited lectures at national and international meetings and published extensively on gas treating, separation processes and carbon dioxide capture in international peer reviewed journals.
Abstract: Removal of CO2 from the flue gas of fossil fuel fired power plants is an urgent requirement in order to reduce CO2 emission to atmosphere and ensure sustainable use of fossil fuels. In this work solvent characteristics of hexamethylenediamine (HMDA), a straight-chain diamine with high CO2 reaction rate and high CO2 capacity are investigated for better CO2 capture economics. Kinetics of CO2 absorption in aqueous HMDA has been found to be in the pseudo-first order reaction regime and the second order rate constant is 42000 m3kmol-1s-1 at 303.15K. It is substantially higher than that of the benchmarked amine for CO2 capture MEA (7600 m3kmol-1s-1). VLE studies of CO2 in aqueous HMDA show that even at a low CO2 partial pressure of 15 kPa, 30mass% HMDA has a CO2 loading as high as 1.123 at 313 K. It is 55% higher than that of MEA. Equilibrium CO2 loading is modeled using the ENRTL theory. Enthalpy of CO2 absorption in aqueous HMDA measured using a reaction calorimeter (model RC1e, Mettler Toledo) is found to be 96 kJ/mol CO2, which is relatively higher than those of MEA,. However, the high CO2 capacity of aqueous HMDA and its high reaction rate more than off-set its relatively higher heat of absorption. From the results of this work and our work on HMDA activated MDEA, HMDA appears to be a much better solvent than other alkanolamines either as a single amine solvent or as an activator for CO2 capture with better capture economics.
Biography: will be update soon..
Abstract: All over the Gulf of Suez, the Miocene sediments seem to have a very important role in oil accumulation. Presence of sandstone streaks in the Hawara Formation which belongs to the Middle Miocene (Serravallian) age in some wells within Ramadan field of relatively high resistivity signature in Electric logs is the main reason to investigate its petrophysical parameters to delineate the main characterization of this sands and to evaluate their ability for hydrocarbon accumulation and production. This members lie between two productive sandstone zone. They can be a good promising reservoir with hydrocarbon potentiality which will be added to the Egyptian oil production. A Petrophysical analysis of this sandstone zone was undertaken using the electric logs and subsurface geologic data to obtain information about the main reservoir characteristics of the studied sandstones. This study revealed that six wells contain hydrocarbon accumulation within this field. Petrophysical analysis of the electrical logs (Resistivity, Density-Neutron, Sonic and Gamma-Ray) of Hawara (S.S.) Members reveals that the shale volume, effective porosity, water saturation, hydrocarbon saturation, and net-pay thickness, are varying between 6 to 18%, 12 to 22%, 18 and 38%, 62 to 82%, and 17 to 37 feet respectively. The types of the present fluids in this reservoir are oil and gas. The hydrocarbon potential of the study area was evaluated through the vertical and the lateral distribution of the petrophysical parameters and hydrocarbon occurrence. The lateral distribution was studied and explained in the form of iso-parametric maps (effective thickness, shale content, effective porosity and hydrocarbon saturation), while the vertical distribution of petrophysical characteristics was studied and explained in the form of litho-saturation crossplots. Also, the hydrocarbon volume was calculated in this zone. All this analyses were performed for Hawara sandstone as one unit.
From the previously mentioned results the following recommendations should be noteworthy: 1- X-A9 , X-A16, X-C14, X-D8A wells for the Hawara Sandstones Member should be perforated, this zone were proved to be oil bearing formations.2-X (A8) and X (B9) wells should be perforated which were proven to be gas zone. 3- Re-evaluaton of all wells in Ramadan field that were correlated with this studied sandy facies should be performed.
Biography: Zeynep Doner is doctorate student and Research Assistant in Geological Engineering of Istanbul Technical University. She received her master’s degree from Ankara University. Her research interest includes the petroleum geology and geochemistry of Silurian black shales in Turkey. Her master thesis is about investigation of hydrocarbon potential of the shales type rocks. She currently interest shale gas potentiality and elemental enrichments related to organic matter in black shales of Central Taurus Belt, South Turkey.
Abstract: The increasing global demand for clean energy has made it imperative to explore for and exploit unconventional oil and gas resources. Silurian (generated 9 % of the world's reserves) is one of the six anoxic stratigraphic intervals that more than 90 % of the original recoverable oil and gas reserves in the world have been generated from source rocks. Silurian black shales from Karabuk area in the northwestern part of Turkey are one of the alternative unconventional gas resources.
For characterizing the organic geochemical properties and hydrocarbon source rock potential, a total of 11 outcrop black shale samples were analyzed by Rock Eval Pyrolysis. The Total Organic Carbon (TOCpd) content at the present time ranging from 0.32 to 1.57 wt. % with an average of 0.63 wt. %. Extremely high unreliable Tmax values (up to 541oC) and low Hydrogen Index (HI) values (1–33 mg HC/g TOC) indicate that these black shales are thermally over mature and seems as a spent hydrocarbon source rock. The remaining hydrocarbon generative potential (S1+S2) between 0.02 and 0.22 mg HC/g rock also supports this conclusion. When plotting the H/C versus O/C atomic ratios on the modified Van Krevelen diagram, the recent organic matter type is Type IV kerogen.
According to interpretive of shale gas potential parameters, based on Jarvie’s equation reconstructed average original values of TOCo is 0.98 wt. %, HIo is 450 mg HC/g TOC, Ro 1.73 % and TRHI is 96.67 % indicating primarily dry gas window and good risk for gas. Overall, these conclusions can have a negative effect on the shale gas potential in the study area and further researches are required.
Biography: Makarova Irina (Saint-Petersburg,Russia). Doctor of Geology
Graduate from Leningrad Univercity.
Working in VNIGRI since 1983 Year.
The Width of the Scientific Interests include Palynology, Stratigraphy,
Oil and Gas Geology, Search of the Untraditional Sources of Hydrocarbons,
Oil and Gas Geochemical Research.
An Author and Co-author of more than 70 Articles of Different Themes,
2 Monographs, including Prischepa O. M., Averyanova O. Yu., Ilinsky A. A., Morariu D. «Oil and Gas in Low-Permeability Shale Strata - Reserve Resource Base of Hydrocarbons, Russia», 2014
and Monograph “Geological Structure and Gas Potential of
Western Slope in the Polar and Subpolar Urals (Based on Exploration Data)”
Abstract: The South Timan-Pechora (oil and gas region,Russia)is characterized bytectonic disturbances,faults and paleo-volcanism. In the oil-and-gas region surroundedUchtaTawn the pyrite-polymetallic ore occurrence is located (Berg,Sivash,2010).The interconnection of processes of magma - and ore formation with the distribution of oil fluidswas considered in the area in accordance with the ConceptGeofluid System. (Muravyeva,Sivash, Мakarova 2015; Sivash, Мakarova, Muravyeva, 2016).
This work is of applied nature of the study of metalstheelementsGeofluidSystem. The main elements Geofluid Systemarethe oil, formation waters,rock, kerogen.The research of various elements GeofluidSystemcausethe necessity of the applicationgroup special physical methods.The optimalcomplexwas picked upduring the experimentinvestigation.It includes:light microscopy,Infrared spectroscopy,gamma spectroscopy,x-ray fluorescence spectroscopy,the method of emission electronics,electron microscopy combined with energy dispersive analysis. The sediments of the upper Devonian, including domanic deposits, are subject to the application of the methods. We stadied, by the severalmethods,distribution ofimportant industrial metals. A number of lithophile and chalcophileelements in rudohorie concentration (close to industrialconcentration).Legacy oil enriched byelements of rocks and hydrothermal waters. The kerogen characterized by specific changes in the area hydrothermal waters in the process of hydrothermogenesis(the term suggested by A. A. Sukhanovfor differences from the catagenicconversion of kerogen (Sukhanov, Yafyasov, Мakarova, 2013). The changes in kerogen and minerals development are the criterions of control of distribution of the hydrothermal waters and oil deposits.Only an optimized set of physical methods provides the reliable data, their comparison, clarification of the distribution of the complex mineral raw materials.This work is an initiative.